Well tester



March 14, i967 B. P. NUTTER 3,308,887

WELL TESTER Filed Dec. 24, 1963 6 Sheets-Sheet l B. P. NUTTER WELLTESTER March 14, 967

6 Sheets-Sheet 2 Filed Dec. 24, 1963 By/A@ March 14, 1967 Filed Dec. 24,1963 B. P. NUTTER WELL TESTER 6 Sheets-Sheet 5 ffy'.

.560/0/27//7 /Va/fer INVENTOR March 14, 1967 B. P. NUTTER 3,308,887

WELL TESTER Filed Dec. 24, 1965 e sheets-sheet 4 ffy@ /47 y 6A U@ @y 1/52 U@ Q9 l ew///v/ /7 /Vaffe/ INVENTOR.

March i4, 967

Filed Dec.

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B. P. NUTTER 3,308,887

WELL TESTER B. F. NUTTER WELL TESTER March 4, 1967 6 Sheets-Sheet 6Filed DGO. 24, 1963 ffy /f Mw www w am Mw/ R15 n M/ W .a n/ m e J4 IIEMw y j w, M w n 22 V w r 7/7//40Z \//////AF United States Patent Gce3,308,887 Patented Mar. 14, 1967 3,308,887 WELL TESTER Benjamin P.Nutter, Houston, Tex., assignor to Schlumberger Well SurveyingCorporation, Houston, Tex., a corporation of Texas Filed Dec. 24, 1963,Ser. No. 333,225 20 Claims. (Cl. 166-150) This invention relates toapparatus for use in a well bore and more particularly to an apparatusfor making multiple flow tests in a well bore.

Drill stem tests are normally performed by lowering a string of toolsincluding a testing tool and packer to a desired depth of testing. Thepacker is set usually Iby applying force through the drill string, thepacker isolating or packing-off the formation to he tested.Suhsequently, a test valve in the testing tool is opened and closed byrotation of the drill string while the force on the drill string islmaintained on the packer. The number of times that such a valve may beopened and closed is limited to one or two separate openings andclosings yand requires a given number of rotations for each operation.Rotation or torquing of the drill string for opening and closingoperations is disadvantageous in that all the threaded connections in atubing string may not be completely made up, therefore the given numberof rotations may be taken up by the string of tubing without effectingan operation of the valve in the tool. Also, the tubing string maybecome lodged in the hole intermediate the length of the tubing so thatthe string of tubing twists above the lodged point without transferringthe rotating motion to the tool. Subsequently, the tubing string maytwist itself free and then make several uncontrolled revolutions on thelower part of the tubing string which may adversely affect the valveoperation. These features of torquing movement involving the uncertaintyof the number of turns of the tubing string give the operator littleevidence of the position of the tool element in the operato perform thevarious operations in the tool.

It is therefore an object of the present invention to provide a new andimproved formation testing apparatus for making multiple flow tests in awell bore with apparatus which utilizes a vertical movement of thetubing string to perform the various operations in the tool.

Another object of the present invention is to provide an apparatus formaking multiple tests of a formation utilizing longitudinal movement ofthe testing tool to perform the test operations.

A t.further object of the present invention is to provide a new andimproved formation testing tool and an apparatus for packing-olf thewell bore in such a way as to facilitate longitudinal movement of thetesting tool and yet maintain the packer in a set condition.

A still further object of the present invention is to provide a new andimproved series of full-opening tools which may 'be used in com-binationwith the new and improved formation tester.

With these and other objects in view, the present invention contemplatesan apparatus for making mutliple tests on a formation. Moreparticular-ly, the apparatus includes a series of tools each includingtelescopically mounted members arranged to selectively move betweenlongitudinally spaced operating positions, the series of tools includingtester means, bypass means, jar means, safety joint means and packermeans.

The tester means includes means permitting opening and closing of a flowvalve by longitudinal stroking movement of the drill string to place thetelescoping members in spaced longitudinal positions and in each of suchpositions, force can positively be applied to the packer.

The bypass means includes means -for quick closing of the valve anddelayed or retarded opening so that the tester valve can be operated.

The jar, and safety joint means are provided to uncouple the tester andtubing string from the packer in the event of sticking and arecompatible to the operation of the tester Valve.

The packer means in one embodiment can be releasably latched againstupward and downward movement in the well bore.

The novel 4features of the present invention are set forth inparticularity in the appended claims. The present invention, both as toits organization and manner of operation together with further objectsand advantages thereof, may best be understood by way of illustrationand example of certain embodiments when taken in conjunction with thelaccompanying drawings in which:

FIG. 1 is a view in elevation of a series of well tools suspended from astring of pipe and arranged for going in a well;

FIG. 2 is an elevationa-l view of an alternative apparatus connected inthe series of tools for isolating the formation to be tested;

FIGS. 3A and 3B are detailed vertical sections of the well testing toolin accordance with the present invention;

FIG. 4 is a developed view of an index slot system used in the tester;

FIG. 5 is a detailed Vertical section of a bypass valve;

FIG. 6 is a detailed vertical section of a safety joint;

FIG. 6A is a cross-sectional view of a safety joint taken along line A-Ao-f FIG. 6;

FIG. 7 is a diagram which shows operating features of the safety joint;

FIGS. 8 and 9 are detailed Vertical sections of a releasa'bly lockedpacker device;

FIG. 10 is an enlarged detailed cross-sectional view taken along line10-10 of FIG. 9 of a valve utilized in the packer device;

FIG. 11 is -a vertical section of an alternative embodiment of thetesting tool and bypass section;

FIGS. 12A and 12B are detailed vertical sections of an alternativecombination of bypass and packer means.

Referring first to FIG. 1, a well tool 20 is -arranged to be connectedto the lower end of a string of pipe or tubing 21 and includes a testersection 22, a bypass section 23, a jar section 24, a safety jointsection 25, a packer section 26, and a perforated anchor section 27. Theanchor carries conventional pressure recorders 28 and has perforations29 in the wall of the anchor section to permit fluid to flow into a borein the packer mandrel and up through the string of tools. Two pressurerecorders are provided, one recorder measuring pressure externally ofthe anchor and the other measuring pressure internally of the anchor.

In the operation of the well tool as shown in FIG. l, the assembled tool20 is attached to the string of pipe 21, and -lowered into the well boreto the formation to be tested. The bypass section 23 of the well toolpermits fluids in the well tbore to bypass `around the packer section 26as the tool is lowered into the well bore and thereby permits a morerapid descent of the tool into the welll bore. When the anchor 27 isseated on the bottom of the borehole, further downward pressure on thetool will cause an elastomer packer element 125 to be expanded in thewell bore to isolate the formation to be tested 'from the rest of thewell bore. Formation fluids enter the tool through the perforations 29in the anchor section and flow upwardly through the various tools to thetester section 22. Valves in the tester section are opened and closed toflow and shut in the formation fluids. 'Die recorders housed in theanchor section are used to measure the pressure of the iluids during theowing and shut-in periods.

FIG. 2 illustrates :an alternative method of locatingthe well tooltester with respect to the formation to be tested wherein a conventionalwall anchor 31 is used to position the tool in the well bore at thedesired depth and a pair of spaced packers 32 and 33 are utilized tostraddle the formation to be tested. The wall anchor 31 is also used toset the packers.

Referring now to FIGS. 3A and 3B, details of the tester section of thetool will now be described. The tester section 22 generally includes .atelescopicallyarranged mandrel 36 and housing 41 respectively arrangedfor coupling between a pipe string 21 and the other sectionsV of thetool. The tester mandrel 36 has a central bore 37 formed therein andintermediate of the Ilength of the bore is a closure plug or barrier 38(FIG. 3B) shear pinned at 39 to the .mandrel and sealingly receivedtherein. The housing 41 is divided into an upper housing section 42 andlower housing section 43 which are rotatablyl connected to one anotherby interlocking and cooperating flanges 46, 47 on the sections 42, 43.Flanges 46, 47 provide a swivel type connection so that the upperhousing 42 can be rotated with respect to the lower housing 43.

The upper housing 42 has an index pin 48 projecting in-to an indexingslot system 49 formed in the mandrel 36. The indexing slot system isshown in a developed View in FIG. 4 and will hereinafter lbe more fullyexplained. The upper housing 42 also has an internal recess 51 with aninwardly-projecting spline or lug 52 disposed intermediate of the lengthof the recess. Housing spline S2 forms an abutment for an upper spline54 projecting outwardly from the mandrel 36 into the housing recess 51.Splines 52, 54 are engaged and disengaged by opera-tion of the slotsystem. Mandrel 36 further has a lower outwardly-extending spline 56which is slidably received within a longitudinally-extending splinegroove 57 in the interior of the lower housing.

The slot system as shown in FIG. 4 includes an upper pocket E, anintermediate pocket H and a pair of lower pockets G and A. The upperpocket and intermediate pocket are longitudinally aligned relative toone another while lower pockets G and A are equidistantly spaced toeither side of the intermediate pocket H. Inclined and longitudinalslots are provided to connect the upper and lower pockets as well 1asthe lower and intermediate pockets to one another and guide the indexpin 48 in a predetermined manner. For example, if the index pin isinitially in the lowermost pocket A, the following sequence of movementswill produce the following described travel of the index pin:

(a) Upon downward movement of the mandrel, the index pin is guided fromthe lower pocket A to the upper pocket E,

('b) Upon upward movement of the mandrel, the index pGin is guided fromthe upper pocket E to the lower pocket (c) Upon downward movement, theindex pin is -guided from the lower pocket G to the intermediate pocketH,

(d) Upon longitudinal movement of the mandrel upwardly relative to theupper housing, the index pin is guided from the intermediate pocket H tothe lower pocket A.

From this description, it will be readily grasped that as the mandrel ismoved longitudinally up and down, the index pin will follow apredetermined .cyclic path. Hence, with the lower housing section 43,held stationary, the spline 56 and spline groove 57 maintain the mandrel36 against rotation and the upper housing section 42 will be rotated byvirtue of the index pin 48 following the slot system 49. l

The slot system functions to place the upper housing spline 52 andmandrel spline 54 in engagement when the index pin is in theintermediate pocket H so that downward forces can be transmitted fromthe mandrel 36 directly to the housing 41 and specifically, lowerhousing section 43 via the splines 52, 54 and the upper housing 42. Inthis manner, the mandrel 36 can be pushed down on the housing 41 toapply weight to the string of tools therebelow. When the index pin ismoved -to the lower pocket A and then toward the upper pocket, thesplines are meshed when the index pin moves 'between points B and C onthe slot system (by virtue of relative rotational displacement) and acollar 58 on the upper end of the mandrel 36 is brought into abuttingrelationship with the upper end 59 of the upper housing 42 when theindex pin is moved to the upper pocket E so that the mandrel can againbe pushed down on the housing.

The lower housing 43, `below the spline grooves 57, has a Ibore portion61 with an enlarged internal diameter forming a cylinder 62 whichreceives a hydraulic delay piston 63 in the form of a sleeve between thecylinder wall and the mandrel. This annulus formed between the bore 61and mandrel 36 is filled with a hydraulic uid and sealed by floatingannular piston and seal members 66 and 67, positioned at each end of the4bore (FIGS. 3A, 3B). The delay piston 63 abuts on one end against anupper, annular valve seat 68 formed by a flange 69 on the mandrel 36. Adelay valve spring 71 is disposed between a lower ange 72 on the mandrel36 and the lower end of the piston 63. Spring 71 normally urges thepiston 63 toward the seat 68 on the valve seat ange 69. The outerdiameter of the piston 63 is less than the diameter of the bore 61 toform a restricted annular orice 73'. Hence, as the mandrel 36 is moveddownwardly relative to the housing 41, the piston 63 seats on the valveseat flange 69 and the ow of hydraulic uid into the cylinder 62 ismetered between the piston 63 and `cylinder wall 61 through therestricted annular oritice 73. This has the eifect of delaying movementof the mandrel 4downwardly relative to the housing.

i At the lower end of the bore 61 is a relief chamber 76 with a largerdiameter so that when the piston 63 is moved into the relief chamber 76,a large Huid ow passage is provided between the piston and the housing.This permits the 'mandrel to jump, or make a sudden movement downwardlyat a terminal portion of its downward travel, causing the collar 58 tostrike and engage the upper end 59 of the housing 41 sending a shockwave to the surface through the string of pipe to -give the operator asurface indication that the index pin 48 is Within the mandrel slot E.

On the other hand, when the mandrel is moved upwardly relative to thehousing, the fluid above the piston 63 will move the piston downwardlyrelative to the mandrel to compress the spring 71. The inner wall of thepiston is provided with longitudinal grooves 77 which permit the fluidto bypass between the piston 63 and the mandrel 36 so that lthe mandrelcan Ibe picked lup relative to the housing relatively fast as comparedto the downward movement of the mandrel.

Below the hydraulic delay system, the housing has a bore portion (FIG.3B) which slidably and sealingly receives the lower end of the mandrel.The housing 'bore portion is recessed to provide an annular ltrap orsample chamber 78 between the housing 41 and mandrel 36. A flow port 79is provided in the bore portion above the recess 78 and extends betweenthe wall of the bore portion and an annular cavity '81 in communicationwith. the

recess. Below the recess in the bore portion, the bore portion issimilarly provided with a ilow port 82 extending between the wall of thebore and an annular cavity y83 in the end of the housing.

The mandrel has spaced sealing elements 86 disposed to either side of arecessed portion 87, the sealing elements being arranged to seal .themandrel 36 relative to the bore above each of the housing flow ports 79,82. The mandrel 36 also has a flow port 88 disposed above the upper sealand above the plug 38. When the mandrel is moved downwardly relative tothe housing, the mandrel recess 87 between the mandrel sealing elementsplaces the lower llow port 82 in communication with the sample chamber78 .and the upper tlow port 79 in communication with the mandrel port88.

The mandrel 36 is threaded on its llower end at 89 so that a portion 36aof the mandrel below the threaded joint may be removed. Removal of thelower portion 36a also removes the lower sealing element 86 and therebyrenders the mandrel 36 incapable of sealing oil the trap chamber 78. Inthis condition, when the mandrel 36 is moved up and down relative to thehousing the lower ow port 82 is placed directly into and out of com--munication with the mandrel port 88 through upper ow port 79 in thehousing.

In FIG. 5 the bypass section 23 of the tool is illustrated. The bypasssection 23 includes a tubular mandrel 91 telescopically received withina tubular housing 92, the mandrel and housing respectively being adaptedfor coupling in the string of tools 20. A spline 93 on the upper part ofthe mandrel cooperates with a spline groove 94 in the bypass housingpermitting relative reciprocation but preventing relative rotationtherebetween. 'I'he spline 93 engages a flange 96 on the housing in anexpanded position of the bypass section while a shoulder 97 on themandrel engages the housing ilange 96 in a contracted position.Intermediate of the housing is a bore portion 98 forming a cylinderwhich slidably receives a tubular sleeve piston 99 slidably mounted forlimited longitudinal movement between a bypass ilange 101 and seatflange 102 on the mandrel. The sleeve piston 99 has a slightly smallerdiameter than the diameter ofthe cylinder bore thereby forming arestricted annular oritce 103. The ends of the annular chamber 98 formedbetween the mandrel and housing are closed by a pair of floating,compensation pistons 106, 107 which enclose a fluid within the chamber.When the mandrel 91 is moved downwardly relative to the housing 92, theuid in the chamber moves the sleeve piston 99 upwardly andlongitudinallyextending grooves 108 in the interior of the sleeve aswell as passageways 109 in the bypass flange permit fluid to easilybypass the sleeve piston 99 and permit the bypass section to be rapidlymoved to a contracted position. However, when the mandrel 91 is movedupwardly relative to the housing 92 to an expanded position, the fluidabove the piston 99 causes the piston to seat on the seat ange 102 andfluid is metered through the restricted annular orice 103 between thesleeve piston and cylinder bore. Hence, the mandrel movement upwardlyrelative to the housing is delayed and retarded.

The lower end of the housing has a bypass port 111 while the lower endof the mandrel has a sealing element 112 so that, in the contractedposition of the mandrel and housing, the bypass port is closed by thesealing element 112 and the compensating piston seal 107.

FIGS. 6, 6A and 7 illustrate the safety joint section 24 of the tool.Referring rst to FIG. 6, the safety joint section includes a tubularmandrel 113 telescopically received within a tubular housing 114, themandrel and housing being adapted for coupling in the string of tools20. A threaded nut 115 is positioned between the mandrel 113 and housing114 and engages threads 120 formed on the upper end of the housing 114.The nut has an internal spline groove 123 formed thereon whichcooperates with an external spline 124 formed on the mandrel 113. Thisspline arrangement provides for longiassembly. At the tudinal movement'between the mandrel and housing of the safety joint but causesrotational movement of the mandrel 113 to be transmitted to the nut 115to rotate the nut relative to the housing. A ilange 145 formed on themandrel 113 limits the upward longitudinal travel of the mandrel withrespect to the housing. Two sets of lugs 146A, 146C and 146B, 146D areformed on the mandrel below the ange 145. The lugs in each set arespaced on the mandrel 180 from each other and the two sets arelongitudinally spaced on the mandrel. Therefore, each of the lugs isspaced from the adjacent lug and is positioned longitudinally therefrom.A longitudinal key 147 is positioned in the wall of the housing 114 andextends into the annular space between the housing and the mandrel. Thekey has a longitudinal dimension which is greater than the longitudinaldistance between the sets of lugs 146B, 146D and 146A, 146C. An annularflange portion 148 formed in the inner bore of the housing 114 hasannular recesses formed therein for receiving seal members 149. Thisange portion having sealing members receives the lower end of themandrel 113 in sliding engagement and seals the mandrel bore 151 fromcommunication with an annular space 152 between the mandrel and housingwhich in turn communicates with the outside of the housing 114.

FIG. 7 shows in a developed view the relationship between the lugs146A-146D and the key 147 as the safety joint is operated. In thestarting position shown in the top diagram the lugs and key arepositioned as shown in the elevational view of FIG. 6, andcross-sectional view FIG. 6A, that is, with the lug 146A positionedabutting the key 147. The second diagram shows that if the mandrel 113is raised relative to the housing 114 and rotated counterclockwise thelug A will be positioned above the key and will rotate with the mandreluntil the lug B abuts the key 147. The third diagram shows thatsubsequently if the mandrel 113 is lowered relative to the housing thelug B will drop below the key 147 and upon rotation of the mandrelcounterclockwise, will rotate reltaive to key 147 until the lug C abutsthe key 147. Thereafter, another upward movement on the mandrel andcounterclockwise rotation of the mandel will raise the lug C above thekey and rotate it 4relative to the key until the lug D abuts the key147, thus completing 270 of rotative movement of the mandrel in the fourdiagrams shown in FIG. 7. As the mandrel 113 is rotating relative to thehousing 114 the splines 123, 124 located on the nut and mandrel,respectively, are meshed to rotate the nut with the mandrel 113. If thelongitudinal rotative movement described relative to FIG. 7 is repeatedenough times the nut 115 will be unscrewed from the mandrel 114whereupon the mandrel 113 will be free to be withdrawn from the housing114 thereby releasing or freeing tool members lpositioned in the toolstring above the safety joint for withdrawal from the well bore.

The packer assembly is shown in FIGS. 8-10. The packer assembly 26includes telescopically-mounted mandrel 116 and housing 117 which arerespectively arranged for coupling to the tool sections above and belowthe lower end of the mandrel is a flange 118 and an annular back-upplate 119. An annular elastomer packing element is received on themandrel between the lower back-up plate and an upper back-up plate 121.The housing has a flange 122 abutting the upper back-up plate. It willbe appreciated that if the housing 117 is moved downwardly relative tothe mandrel 116, the packing element 125 can be expanded to engage thewall of the well bore as shown in FIG. 9.

In the upper part of the mandrel and housing is a system for releasablyretaining the packer element in an expanded condition. For this systemthe mandrel has upper 126 and lower flange portions slidably andsealingly received in the housing and forming a recess or chamber 128,129 therebetween, the chamber being lled with a hydraulic fluid. Thehousing has an inwardly-extending second 157 passageways from oneanother.

piston 131 which is slidably received in the chamber and forms upper 128and lower 129 recess portions. Upper 132 and lower 133 passagewaysextend longitudinally through the piston to a Valve 134. It will beappreciated The fluid leakage mentioned above is for the purpose ofobtaining release of the valve eventually should a malfunction occur.Thus the packer is never irretrievably set in the well bore.

that if the valve is opened in the position shown in FIG. Thedifferential pressures to control the spool valve are S, connecting theupper 132 and lower 133 passageways obtained in a manner which willhereinafter be more fully to one another, fluid will pass from the lowerrecess explained. portion 129 to the upper recess portion 128 when theThe operation of the apparatus of FIGS. 3-1() may housing 117 is moveddownwardly relative to the mandrel best be understood by use of thefollowing table in con- 116 to the position shown in FIG. 9. With thepacker nection with the description following.

Going in Set-ting packer Open tester Close tester Tester sectionExpanded Expanded, slowly mov- Contracted Expanded to intermediing tocontracted ate position. A A toward C C to E E to G to H. u }N0t engagedNot engaged Engaged N ot engaged.

Splines 52, 54 Not engaged Engaged.

Test port 88 Open Closed.

Sample chamber 78. do Do.

Bypass section 23 Contracted Contracted.

Bypass port 11l Closed Closed.

Packer section 25 Expanded Contracted Contracted Contracted.

Packer element l25 Contracted Expanded Expanded Expanded.

Valve 134 Open Open Closed Closed.

element 26 expanded, closing of the valve 134 and taking 30 Condition 1the upper 132 and lower 133 passageways out of communication will trapfluid in the upper recess portion 12S and prevent thev housing frommoving upwardly relative to the mandrel.

The valve system includes a port 135 in the mandrel 116 opening to arecessed portion 136 of the piston between spaced seals 137 and acontrol port 138 in the piston opening to the valve 134. As shown inFIG. l0, the valve includes a sleeve 141 retained in a bore 142 of thehousing, the sleeve 141 having a` first vannular groove 143 and ports incommunication with a first passage 144 and a second annular groove andports 156 in communication with a second passageway 157. It will beappreciated that FIG. 10 illustrates both `upper 132 and lower 133passageways for convenience of understanding although one of thepassageways would not 'be seen in the section view. The illustrationalso `demonstrates that the upper and lower passageways are offsetrelative to one -another at their access points to the valve. A bore 158inthe sleeve 141 opens at one end to the exterior of the tool and at theother end to the control port 138. Received in the sleeve bore is aspool type piston 159 arranged for movement between a position placingthe upper and lower passageways 132, 133 in 4communication and aposition where the upper and lower passageways are isolated from oneanother. A spring 161 is provided to normally urge the piston to aposition placing the passageways in fluid communication with oneanother. The piston in the position illustrated has a first portion 162closing olf the sleeve ports leading to passageway, the first portion,however, having a slightly smaller diameter than the bore of the sleevepermitting some fluid leakage to occur. When uid pressure exterior ofthe housing is greater than fluid pressure atthe control port 138 (whichis connected by the piston recess 136 and mandrel port 135 to theinterior of the mandrel) and the force of the spring 161, the piston 159will assume the illustrated position where the first portion 162 of thepiston isolates the first 144 and When the fluid pressure exterior ofthe housing is less than the iluid pressure at the control port 138 andthe force of the spring 161, the piston is shifted so that a recessedportion 163 ofthe piston places passageways 144, 157 in communicationwith one another.

v In going-in the well bore, the various elements and tool parts are inthe conditions above noted. In the packer assembly, the valve 134 (FIG.l0) is open because the pressure of the fluids within the packer mandrel116 are the same as the pressure of the fluids on the exterior of thetool so that the spring 161 places the spool piston 159 in a positionwhere the upper and lower passageways 132, 133 are in uid communication.

The bypass 23 is held in an expanded position by the weight of the toolattached to the bypass housing 92 so that the bypass port 119 is openand fluid can pass through the packer mandrel 116 and return tothe Wellbore via the bypassport 111.

In the testing section, the sample chamber 78 and test ports are closedwhile the index pin is disposed in the pocket A.

Condition 2 Upon reaching the level of the test, the packer element isexpanded. This occurs because the packer mandrel 116 is xed relative tothe well bore. Fixing the mandrel may be by contact with the bottom bythe perforated anchor 27 or by setting a hook wall anchor as shown inFIG. 2. It should be noted that for use of a hook wall packer, theconventional J slot control can be operated because all of the sectionsare spline connected to permit rotation. While splines are not shown inthe packer assembly 26, it will be appreciated that this connection caneasily be furnished between the mandrel 116 and upper housing 117.

As stated heretofore, the packer mandrel is fixed and a downwardy motionon the string of pipe is transmitted through the tool sections to movethe upper packer housing 117 relative to the packer mandrel 116 andexpand the packer element 125. As the packer element expands, the bypasssection 23 contracts to close the bypass port 111 bringing the bypassmandrel shoulder 97 into abutment with the bypass housing. In the testersection the fluid in the delay system is trapped 4below the piston 63and very slowly meters through the restricted orifice 73.

Condition 3 After the packer is fully expanded,l the delay piston 63 inthe tester section reaches the recessed portion 76 and very quicklypermits the tester mandrel and housing to contract and very quicklyopens the mandrel test port 88 and sampling chamber 78 to the bore ofthe Well tool which extends down to the perforated anchor 27 below theexpanded packer. This quick motion is apparent at the earths surface aswas heretofore described and gives an indication to the operation thatthe tool is properly operating. Because the interior of the string ofpipe and the formation pressures are considerably less than thehydrostatic pressure of the well uid above the expanded packer, thevalve 134 in the packer is closed trapping fluid in the upper recess 128of the packer assembly. At this time, the tester mandrel shoulder 58engages the upper housing end 59, the bypass shoulder 97 engages thebypass housing 92 and downward pressure on the string of pipe can bemaintained on the packer element to ensure that it will be fullyexpanded. During this condition, the index pin has traveled fromposition C into the slot E.

Condition 4 After fluid has flowed for a sufficient period of time, sayfteen minutes, the tester is closed for, say, five minutes to obtain ashut-in pressure. To close the tester the string of pipe is picked up asuicient distance to index the pin from the upper pocket E to the lowerpocket G and then set down to index the pin to the intermediate pocketH.

In picking up the string of pipe, the delay valve in the tester opens topermit quick bypass of iluid and movement of the tester section to theexpanded condition. At the same time, the delay valve in the bypassretards movement of the bypass to an expanded position and the closedvalve 134 in the packer assembly prevents release of the expanded packerelement 125. The splines 52, 54 in the tester section are meshed onceagain and the mandrel spline 54 disposed above the housing spline 52.Thus, when the string of pipe is set down and the index pin goes to theintermediate pocket H the splines are brought into abutment and directforce on the string of pipe is once again directly transmitted to thebypass and packer sections to maintain the packer element expanded toclose oi the formation while the pressure of the formation fluids ismeasured.

When the tester, with the mandrel end 36A threaded at 89 to the testermandrel, is closed, a uid sample is trapped in the sample chamber 78. Ifit is desired to retrieve the well tool, picking up the drill pipe movesthe index pin from pocket H to pocket A.

On the other hand, it is often desirable to repeat the above sequence ofoperations a number of times which permits formation conditions to bedetermined by analysis of sequential shut-in and build-up pressurerecordings. This may be done by repeating the up and down movements ofthe tester mandrel as set forth above.

To determine when the Huid recovery is formation fluids, a gas flowmeter19 (FIG. l) is connected to the string of pipe at the surface. As fluidsenter the string of pipe the displacement of air in the pipe isindicated by the flowmeter. At a point where the formation uid owstabilizes the gas flow becomes constant indicating completion of thetest.

Tool retrieval In order to retrieve the tool string 20 and the fluidsample which may be trapped in the chamber 78 when end section 36a isattached to the tester mandrel, the packer element 125 must becontracted to release the tools from the well bore. This step may 4beaccomplished by picking up on the tool string to close the tester valveand trap a iluid sample at formation pressures. Thereafter, the bypassmandrel 91 is lifted up relative to the bypass housing 92. A continuedlifting force on the mandrel 91 will permit sutlicient lluids to leak bythe bypass piston 99 through the restricted orice 103 to allow themandrel and seal 112 to uncover the bypass port 111. The opening of port111 subjects the inner bore of the tool sections to the hydrostaticpressure of the well uids thereby increasing the inner bore pressure andconsequently communicating the increased pressure with the control port4138 of the packer. This pressure in turn acts with spring 161 to movethe piston 159 forward and open the valve 134 to connect the upper andlower passageways 132 and 13-3. The valve opening permits expandingmovement of the l'packer mandrel and housing to release the packerelement 125 from compression and engagement with the well bore.

Further upward movement of the tubing string w-ill withdraw the toolstring from the well bore. \If for some reason the tool or strin-g ofpipe should become lodged or stuck in the well bore a jar section isprovided in the tool string to permit a jarring force to be applied tothe tool string. The jar section 24 (FIG. 1) may be of the type setforth in a vco-pending application for Well Jar Systems, Ser. No.280,829 now Patent No. 3,251,426, and owned by the assignee of thepresent invention.

IIf the tool string should not become dislodged from the well bore bythe use of the jar, the safety joint 25, described heretofore in thedescription, may lbe utilized. The tubing string is rotated above thesafety joint to release t-he upper part of the string for retrieval tothe surfa-ce. In order to affect the loosening of the threads in thesafety joint or other pipe joints below the safety joint, it may benecessary to lower an explosive element or string shot into the fullopen bore of the tool string to the level of the joint whereupon theshot is detonated to loosen the joint for subsequent unthreading byrotation of the tubing string. The knock out plug 38 which serves thepurpose of blocking the tester section mandrel bore 37 during flowtesting of the well may be removed by dropping an object in the bore ofthe tubing string which object serves to shear the pin 39 to knock outthe plug 38. This opens the bore for lowering of the string shot to thesafety joint section 25.

After retrieving the tool to the surface, it is necessary to analyze thesample trapped in the chamber 78 at the conditions under which it wastrapped. To eifect this purpose, a plug 85 is threadably received in'thewall of the lower tester housnig 43 (FIG. 6B). Manipulation of thetester members will permit sealing oif of this plug port for removal ofthe plu-g and insertion of test instruments while maintaining the sampleat reservoir conditions. Subsequently, the tester mandrel is moved touncover the plug port and place the instruments in communication withthe sample chamber for analysis of the trapped fluid.

T-he applicant has set forth a preferred embodiment of the apparatus toperform the multiple testing operation. There are many forms ofapparatus which could be utilized to perform this method of operation.One such alternative embodiment of a tester and bypass section of thetool is shown schematically in FIG. 11.

The tester and bypass section shown in FIG. l1 includes a tester section173 which has an index system and spline arrangement similar to thatdescribed with reference to the tester embodiment shown in FIGS. 3A and3B. Likewise, the hydraulic delay piston shown in the embodiment inFIGS. 3A and 3B may be utilized in this embodiment although not shown inFIG. 11. The tester section further has an ori-tice plug 174 positionedin a tester mandrel 176. A tester housing 177 likewise has a plug 178positioned in -a bore formed in the housing and connected to the housingby spider-fingers 179 arranged around the bore of the housing. Thesefingers, being spaced apart, permit uid flow Iaround the plug 178. Abore formed in the tester mandrel is sized to slide over the plug 178positioned in the tester housing and a seal member 181 which is formedon the plug 178 serves to seal the bore of the tester mandrel from thebore of the tester housing.

In the operation of this tester the tester mandrel is raised by anupward movement on the drill pipe to expose the bottom of the testermandrel bore to formation fluids owing into the tester housing frombelow as indicated by the arrows in FIG. 11. T o close the tester,-downward movement on the tester mandrel places the tester mandrel boreover the plug 178 and seal member 181 to seal the tester mandrel borefrom fluids owing into the tester housing.

The bypass section 186, which is suspended below the tester section 173,has a mandrel 187 that is hreadedly secured at its upper end to thebottom of the tester housing, the lofwer end portion beingtelescopically connected to a bypass housing 188 by any suitable means(not shown), for example the spline, groove and flange arrangementsshown in FIG. 5. A bypass housing 188 has bypass ports 189 formedtherein. A seal 191 which is positioned on the bypass mandrel serves toseal off the bypass ports 189 when the bypass mandrel is in a downposition as shown in FIG. ll. Upward movement on the bypass mandrel willposition the seal 191 above Vthe port 189 to provide fluid communicationfrom the interior of the bypass section to the annular space in the wellbore. A packer 192 which is positioned below the bypass 186 may dependfor its expanded condition upon the bypass valve or port 189 beingclosed to prevent hydrostatic pressure in the well bore from enteringthe interior of the bypass housing. Therefore, the maintenance of thebypass in a 1closed position is important and will be explained.

The -bypass is maintained in its closed position by the action of iiuidforces on exposed areas of the tester and bypass members (FIG, 1l).After the bypass is closed, the forces, which act down on the testerhousing and bypass mandrel, are maintained greater than the forcesacting up on the tester housing and bypass mandrel. The forces actingdown can be calculated by multiplying the hydrostatic pressure in thewell bore Ph times the difference between the area of the tester housingandthe area of the ltester mandrel (A1-A2). The forces acting up on thesystem may be calculated by multiplying the hydrostatic pressure Phtimes the area of the testerhousing minus the area of the bypass mandrel(A1-A3) plus the formation pressures Pf times the area of the bypassmandrel minus the area of the tester mandrel (A3-A2). The lattercalculation,`A3-A2, represents the effective area of the tool subjectedto formation pressures which is in effect the difference in areasbetween the top and bottom of the bypass mandrel 187 that is exposed toformation fluid. The total force Fd down may be calculated bysubtracting the forces up from the forces down as shown in the followingequation:

Fa=Ph(A1-2) -Ph(A1-a)-Pf(Aa-*2) (1) Fd=Pn(3-A2) -Pf(As-A2) (2)Fd=(Ph-Pf)(a-A2) (3) Therefore, if the hydrostatic pressure in the wellbore is maintained greater than the formationV pressure, the forcesacting on the tester and bypass after closure of the bypass valve willserve to maintain the bypass valve in closed position.

In order to open the bypass, an upward acting force must be applied tothe tester housing and bypass mandrel which will overcome thepredominant downward forces. This is accomplished by applying liftingforce on the tubing string which is sufficient to shift the balance offorces in an upward direction.

It may be appreciated from the foregoing discussion of this alternativebypass system that longitudinal upward and downward movements of thetubing string to manipulate the multiple test section would not open thebypass but rather an upward force calculated tovshift the balance offorces must be applied to the bypass mandrel to open the-bypass.

An alternative bypass and packer which is the subject of applicantsPatent No. 3,020,959 for Well Packers is shown in FIGS. 12A and 12B.This packer and bypass tool includes a mandrel 201 and a housing 202. Aseries of openings 203 in the mandrel wall provide a bypass for fluidsaround a packer element 204, when expanded, which is positioned on theouter wall of the housing 202. The mandrel is slidably received withinthe housing and upon downward movement of the mandrel with respect tothe housing, seals 206 positioned in the mandrel above the bypass ports203 are received within a recess 207 formed in the upper end of thehousing to seal off the bypass ports from the well bore above the packerelement 204. The same downward movement of the mandrel is used to setthe packer. However, before downward movement of the mandrel relative tothe housing is possible, it is necessary to rotate the tubing string tothe right while lowering it to screw the mandrel through a split nut 209received between the mandrel and housing. After the bypass has closed,the further downward movement on the mandrel is transferred to an upperhousing member 211 and this section is moved relative to a lower housing212 which resists longitudinal movement because of the contact of afriction pad 213 with the -Wall of the well bore. Thus, downwardmovement is transmitted through the upper housing 211 to an expander 214which wedges slips 216 outwardly into gripping contact with the casing.Thereafter, motion of the expander and attached lower packer shoe 217ceases and further downward motion of the mandrel assembly serves tocompress the elastomer packer element 204. During the downward travel ofthe mandrel assembly buttress threads 218 formed on the mandrel ratchetthrough an upper split nut 219. The upper split nut acts in the oppositedirection from the lower split nut 209 in that an upward pull on mandrel208 will not produce movement thereof relative to the housing assembly.Upward motion of the mandrel 208 when the packer is set is dimited bythe engagement of the upper edge on the split nut 219 with a shoulder221 formed on the housing. This locking of the mandrel is advantageousin that an upward pull on the mandrel cannot open the bypass ports ortend to unseat the packer. This is particularly useful when the packeris used in conjunction with an auxiliary tool such as a formation testerwhich requires longitudinal movement of the tubing string to operate`the tester.

To unseat the packer it is necessary to first release the threadedengagement between the upper split nut l219 and the mandrel assembly.This is accomplished by rotating the tubing string to the Vright andsimultaneously exerting a pull thereon. When disengaged, the mandrelassembly is pulled upwardly to expose the bypass ports to the well fluidthereby equalizing the pressure above and below the packer. Thereafterupward motion of the mandrel assembly is transmitted to the upperhousing 211 to exert tension on the packer element 204 and return it toits uncompressed original shape. At the same time the expander slips 216are retracted and the mandrel buttress threads 218 ratchet back through.the lower split nut. The packer may now be retrieved from the well.

Should the wall engaging portions fail to unseat properly, a jar and asafety joint may be provided in the tool string to facilitate retrievalof the well tool in such emergencies. The packer and bypass tool isfull-opening to allow for lowering of or retrieval of other smalldiameter tools through the bore of the tool.

Different well testing apparatus is usually designed for use in open andcased well bores. Although this invention is primarily directed toapparatus for testing open well bores it will be appreciated thatfeatures of the present invention can have application for testingapparatus for cased well bores.

i3 While particular embodiments of the present invention have been shownand described, it is apparent that changes and modifications may be madewithout departing from this invention in its broader aspects and,therefore, the aim in the appended claims is to cover all such changesand modiiications as fall within the true spirit and scope of thisinvention.

What is claimed is: 1. Apparatus for testing earth formation conditionsin a well bore containing well fluids comprising:

flow conduit means extendible in a well bore to earth formations to betested and including a string of pipe, tester means, and packing-offmeans, said packing-off means being below said tester means and arrangedto selectively isolate a section of the well bore from the well lluidtherein, said tester means including telescoping tubular members, one ofsaid members having rotatively coupled parts, one of said parts havinglongitudinally spaced abutments, the other of said members having anabutment, and indexing means between said one part and said other memberfor selectively positioning said other member abutment on one of saidpart abutments by longitudinal movement of said other member androtation of said one part. 2. Apparatus for testing earth formationconditions in a well bore containing well fluids comprising:

packing-ofic means dependently coupled to tester means, saidpacking-ofic means being arranged to selectively isolate a section ofthe Well bore from the well fluid therein, said tester means havingtelescopically arranged members adapted for coupling between a string ofpipe and said packing-off means and longitudinally movable betweencontracted and expanded positions, valve means in said tester means forselectively opening said tester means to fluid flow in one of saidpositions and closing said tester means to iluid ow in the other of saidpositions, one of said tester members having secured to one another, oneof said parts and said other member respectively having abutment meansproviding at least two longitudinal positions of abutment, and Y meansinterconnecting said one part and said other tester member forselectively positioning said abutment means in said positions. 3,Apparatus for testing earth formation conditions in a well borecontaining well fluids comprising:

packing-off means dependently coupled to tester means, said packing-H?means being arranged to selectively isolate a section of the well borefrom the well uid therein by the application of a downward force, saidtester means having telescopically arranged members adapted for couplingbetween a string of pipe and said packing-off means and longitudinallymovable between contracted and expanded positions, valve means in saidtester means for selectively opening said tester means to fluid ow inone of said positions and closing said tester means to fluid flow in theother of said positions, one of said tester members having partsrotatively secured to one another, one of said parts and said othermember respectively having abutment means providing at least twolongitudinal positions of abutment, and indexing means interconnectingsaid one part and said other tester member for selectively positioningsaid abutment means in said positions whereby a downward force can beapplied in each of said positions. 4. Apparatus -for testing earthformation conditions in a well bore containing Well liuids comprising:

packing-oli means dependently coupled to tester means,

parts rotatively said packing-off means being arranged to selectivelyisolate a section of the well bore from the well liuid therein by theapplication of a downward force,

said tester means having telescopically arranged members adapted forcoupling between a string of pipe and said packing-oilc means andlongitudinally movable between contracted and expanded positions,

valve means in said tester means for selectively opening said testermeans to fluid flow in one of said positions and closing said testermeans to uid flow in the other of said positions,

one of said tester members having parts rotatively secured to oneanother,

one of said parts and said other member respectively having abutmentmeans providing at least two longitudinal positions of abutment,

indexing means interconnecting said one part and said other testermember for selectively positioning said abutment means in said positionswhereby a downward force can be applied in each of said positions, and

means for delaying telescopic movement of said tester members to aposition opening said valve means.

5. A well tool lfor use in a Well bore,

a first tubular member,

a second tubular member having a longitudinal opening therethrough andslidably received within said rst tubular member,

barrier means in one of said members dividing said longitudinal openingthrough said member into an upper and lower passageway,

means for limiting relative movement between said members for at leasttwo longitudinal positions,

said means including spaced abutment means arranged for contact inspaced longitudinal positions for transmitting downward forces in saidspaced longitudinal positions,

valve means in said members operative for connecting said upper andlower passageways in one of said positions to permit fluids to pass fromone of said passageways to the other of said passageways and operativein said other position for closing said passageways from fluidcommunication with one another,

means for positioning said abutment means by reciprocating motionbetween said first and second tubular members, and

delay means for retarding longitudinal movement between said rst andsecond tubular members when moving toward a position where said valvemeans permit the passage of iluid between said passageways.

6. A well tool for use in a well bore,

a first tubular member,

a second tubular member having a longitudinal opening therethrough andslidably received for telescoping movement within said first tubularmember,

barrier means in one of said members dividing said longitudinal openingthrough said second tubular member into an upper and lower passageway,

means coengageable between said members for limiting `relative movementbetween said members for at least two longitudinal positions,

said means including spaced abutments arranged for contact in spacedlongitudinal positions for transmitting downward forces in said spacedlongitudinal positions,

valve means in said members operative for connecting said upper andlower passageways in one of said positions to permit iiuid to pass fromone of said passageways to the other of said passageways and operativein said other position for closing said passageways from Huidcommunication with one another,

means for positioning said abutment means by reciprocating motionbetween said first and second tubular members,

delay means for retarding longitudinal movement between said first andsecond tubular members when moving toward a relative position where saidvalve means connect said passageways,

said delay means having shunt means permitting relatively fasttelescoping movement between said first and second tubular members whenmoving toward the relative position where said valve means close saidpassageways.

7. Apparatus for use in a well bore, comprising:

arirst tubular member,

a second tubular member having a longitudinal opening therethrough andslidably received within said first tubular member,

removable closure means in said second tubular member dividing saidlongitudinal opening therethrough into an upper and lower passageway, Y

coengaging means on said members for limiting relative movement betweensaid members for at least two longitudinal positions,

valve means in said members operative for connecting said upper andlower passageways in one of said positions to permit uids to pass tromone of said passageways to the other of said passageways and operativein another of said positions for closing said passageways from fluidcommunication with one another,

bypass means arranged for coupling to said tubular members,

said bypass means having a mandrel and housing,

said bypass mandrel and housing being relatively movable betweenexpanded and contracted positions and including valve means providing aliuid communication path between the exterior and interior of the wellapparatus in one of said positions, and

means for restricting relative movement between said bypass mandrel andhousing when said bypass valve means is closed.

8. Apparatus in a well bore containing a well tluid for ow testing thewell including:

telescopically arranged tester members movable between spacedlongitudinal positions,

valve means in said tester members for controlling ilow through saidtester members in said positions,

packer means including telescopically mounted members, and a packerelement disposed on one of said packer lmembers and arranged to beexpanded by relative motion between said telescoping packer members,

means for releasably holding said telescoping packer members againstmovement when said packer element is expanded,

bypass valve means intermediate said tester members and said packermembers for providing a uid communication path between the annulusspaces in said well bore .above and below said packer means,

said bypass `means further including telescopically arranged tubularmembers movable between expanded and contracted positions,

means for delaying the movement of said bypass members to a positionwherein said fluid communication path is provided, and

safety joint means intermediate said tester members and said packingmeans, said safety joint means including telescoping members mounted forlongitudinal movement and arranged to selectively resist rota-tivemovement,

said safety joint members capable of being rendered separable by aseries of longitudinal and rotative motions on one of said members,

said safety joint means, bypass means, packer means and tester meanseach having a full-opening bore therethrough.

9. Apparatus for testing earth formations in a well bore containing welli'luids comprising telescopieally arranged inner and outer tubularmembers adapted for coupling between a string of pipe and packer means,

l5 said inner tubular members having a removable plug portion normallyclosing off its bore, a test port above said plug portion, and sealmeans on said inner tubular members below said port, said outer tubularmember having a bore portion with longitudinal spaced openings in fluidcommunication with one another .through the body of said tubular member,

means permitting longitudinal movement of said members relative to oneanother between positions where said seal means is above said spacedopenings and intermediate of said spaced opening abutment means on saidmembers engageable in each of said positions for transmitting downwardlydirected forces from said inner member to said outer member, and shearmeans for releasably securing said plug portion within the bore of saidinner tubular member so that said plug portion can be removed to providea straight-through access passageway through said members. I

l0. A well testing tool comprising: first and second telescopicallyarranged members adapted for coupling in a tool string, said membershaving passageways and valve means for selectively placing saidpassageways in cornmunication, means securing said members to oneanother, at least one abutment means mounted on one of said members forrotation relative to both of said members, at least one abutment meansmounted on the other ot said members, and index means including cammeans cooperable between said first mentioned abutment means and one ofsaid members for positioning said abutment means in engagement in onelongitudinal position of said members whereby forces in one directioncan be transmited from one of said members to the other through saidabutment means and for rotating said first mentioned abutment meansrelative to both of said members in response to longitudinal motion ofone of said members to disengage said abutment means to permit relativemovement of said members to another longitudinal position.

11. A well testing tool comprising first and second telescopicallyarranged members adapted for coupling in a well string, said membershaving passageways and valve means for selectively placing saidpassageways in cornmunication, means securing said members to oneanother, at least one abutment means mounted on one of said members forrotation relative to both of said members, at least one abutment meansmounted on the other of said members, index means for positioning saidabutment means in engagement in one longitudinal position of saidmembers for transmitting forces in one Adirection and operable to-disengage said abutment means to permit movement of said members toanother longitudinal position, and means on said members engageable insaid other longitudinal position for transmitting forces in said onedirection.

12. A flow evaluating tool for use in a well bore, said tool havinginner and outer tubular members telescopically movable between first andsecond relative positions, said members having passageways and valvemeans placing said passageways in communication in one of the relativepositions and out of communication in the other of the relativepositions, -a first abutment on one of said members, a second abutmenton the other of said members engageable with said first abutment whensaid members are in the relative position where said passageways are outof communication so that downward forces can be transmitted from onemember to the other, and index means separate from said abutment meansfor angularly displacing one of said abutments relative to the other todisengage said abutments so said members can be moved to the relativeposition where said passageways are placed in communication` 13. A flowevaluating tool for use in a well bore, said tool having inner and outertubular members telescopical- 1y movable between rst and second relativepositions,

said members having pasageways and valve means placing said passagewaysin communication in Vone of the relative positions and out ofcommunication in the other of the relative positions, one of saidmembers having a rotatable portion, a first abutment on said rotatableportion, a second abutment on the other of said members engageable withsaid first abutment when said members are in the relative position wheresaid pasageways are out of communication so that downward forces can betransmitted from one member to the other, index means for angularlydisplacing one of said abutments relative to the other to disengage saidabutments so that said members can be moved to the relative positionwhere said passageways are placed in communication, and a third abutmenton said one of said members longitudinally spaced from said firstabutment and engageable with said other of said members when saidmembers are in the relative position where said passageways are placedin communication so that downward forces can be transmitted from onemember to the other.

14. A well tool comprising: inner and outer tubular memberstelescopically movable lbetween first and second relative positions,said members having passageways and valve means placing said passagewaysin communication in one of the relative positions and out ofcommunication in the other of the relative positions; a first abutmenton one of said members; a second abutment on the other of said membersengageable with said first abutment when said members are in therelative position where said passageways are out of communication sothat downward forces can be transmitted from one member to the other;and index means, including a part rotatable relative to said memberssolely responsive to longitudinal reciprocation of one of said members,for angularly displacing one of said abutments relative to the -other todisengage said abutments so that said members can be moved to therelative position where said passageways are placed in communication.

1S. Apparatus for testing earth formation conditions in a well borecontaining well fluids comprising: flow conduit means extendible in thewell bore to the earth formations to be tested and including a string ofpipe, tester means, and packingolf means, said packing-ofi me-ans beingbelow said tester means and arranged to selectively isolate a section ofthe well bore from the well fluid therein, said tester means includingtelescoping tubular members, one of said members having relativelyrotatable parts and longitudinally spaced abutments, the other of saidmembers having an abutment, and indexing means between one of said partsand said other member for selectively positioning said other memberabutment on one of said abutments on said parts by longitudinal movementof said other member `and rotation of one of said parts.

16. Apparatus for testing earth formation conditions in a well borecontaining well fiuids comprising: packingoff means dependently coupled.to tester means, said packing-off means being arranged to selectivelyisolate a section of the well bore from the well uid therein, saidtester means having telescopically arranged members adapted for couplingbetween a string of pipe and said packing-off means and longitudinallymovable between contracted and expanded positions, valve means in saidtester means for selectively opening said tester means to Huid flow inone of said positions and closing said tester means to fiuid ow in theother of said positions, one of said tester members having relativelyrotatable parts, said parts and said other members respectively havingabutment means providing at least two longitudinal positions of butment,and means interacting between one of said parts and said other testermember for selectively positioning said abutment means in saidpositions.

17. Apparatus for testing earth formation conditions in a well borecontaining well fluids comprising: packingoff means dependently coupledto tester means, said packing-off means being arranged to selectivelyisolate a section of the well bore from the well fluid therein by theapplication of a downward force, said tester means having telescopicallyarranged members adapted for coupling between the string of pipe andsaid packing-off means and longitudinally movable between contracted andexpanded positions, valve means in said tester means for selectivelyopening said tester means to liuid` flow in one of said positions andclosing said tester means to fluid flow in the other of `said positions,one `of said tester members having relatively rotatable parts, said.parts and said other members respectively having abutment meansproviding at least two longitudinal positions of abutment, indexingmeans interacting between said parts and said other tester member forselectively positioning said abutment means in said positions wherebydownward force can be applied in each of said positions, and means fordelaying telescopic movement of said tester members to a positionopening said valve means.

18. Apparatus in a well bore containing well liuid for flow testing thewell including: telescopically arranged tester members movable betweenspaced longitudinal positions, valve means in said tester members forcontrolling flow through said tester members in said positions, packermeans including telescopically mounted members, and a packer elementdisposed on one of said packer members and arranged to be expanded byrelative motion betweenv'said telescoping packer members, means forreleasably holding said telescopic packer members against movement whensaid packer element is expanded, by-pass valve means intermediate saidtester -members and said packer members providing a fiuid communicationpath between the annular spaces in s-aid well bore above and below saidpacker means, said by-pass means further including teles-copicallyarranged tubular members movable between expanded and contractedpositions, means for delaying the movement of said lby-pass members to aposition wherein said fluid communication path is provided, and safetyjoint means operable in response to manipulation of the string of pipe.

19. A well tool for use in a well bore, a first tubular member having yabore therein, a second tubular member having a longitudinal openingtherethrough and slidably received for telescoping movement within saidfirst tubular member lbetween at least two longitudinal relativepositions, removable closure means in one of said members for dividingsaid bore and longitudinal opening into an upper and lower passageway,means for limiting relative movement between said members in said atleast two positions so that forces on one of said members can betransmitted to the other of said members in each of said relativepositions, valve means in said members operative for connecting saidupper and lower passageways in one of said positions to permit uids toflow from one of said passageways to the other of said passageways andoperative in another of said positions for closing said passageways fromfiuid communication with one another, and shear release means connectingsaid closure means to said one of said members so that said closuremeans can be forceably removed by dropping a weighted member through theinner tubular member to provide said members with a longitudinal accesspassageway therethrough.

20. A well tool for use in a well bore, a first tubular member, a secondtubular member having a longitudinal opening therethrough and slidablyreceived for telescoping movement within said first tubular member,barrier means in one of said members dividing said longitudinal openingthrough said member into an upper and lower passageway, means on saidmembers for limiting relative movement between said members for at leasttwo longitudinal positions, said means including spaced abutment meansarranged for engagement in spaced longitudinal positions forltransmitting downward forces in said longitudinal positions, Valvemeans in said members operative for connecting said upper and lowerpassageways in one senses? of said positions Vto permit Hinds to passfrom one of the said passageways to the other of said passageway/s andjoperative in said other positionfor closing said passage- ReferentesCited by the `Examiner UNITED STATESl PATENTS Re. 24,352 S/1857 COmStOCk166-145 20 Huber 166-152 Nutter 166-152 X Nutter 166-134 Fisher 166-131Andrew et al. 166-148 Nutter 166--226 Crowe 166-226 Chisholm 166-152 XJACOB L. NACKBNOFF, Primary Examiner.

CARLES E. OCONNBLL, Examiner D. H. BROWN, Assistant Examiner.

10. A WELL TESTING TOOL COMPRISING: FIRST AND SECOND TELESCOPICALLYARRANGED MEMBERS ADAPTED FOR COUPLING IN A TOOL STRING, SAID MEMBERSHAVING PASSAGEWAYS AND VALVE MEANS FOR SELECTIVELY PLACING SAIDPASSAGEWAYS IN COMMUNICATION, MEANS SECURING SAID MEMBERS TO ONEANOTHER, AT LEAST ONE ABUTMENT MEANS MOUNTED ON ONE OF SAID MEMBERS FORROTATION RELATIVE TO BOTH OF SAID MEMBERS, AT LEAST ONE ABUTMENT MEANSMOUNTED ON THE OTHER OF SAID MEMBERS, AND INDEX MEANS INCLUDING CAMMEANS COOPERABLE BETWEEN SAID FIRST MENTIONED ABUTMENT MEANS AND ONE OFSAID MEMBERS FOR POSITIONING SAID ABUTMENT MEANS IN ENGAGEMENT IN ONELONGITUDINAL POSITION OF SAID MEMBERS WHEREBY FORCES IN ONE DIRECTIONCAN BE TRANSMITTED FROM ONE OF SAID MEMBERS TO THE OTHER THROUGH SAIDABUTMENT MEANS AND FOR ROTATING SAID FIRST MENTIONED ABUTMENT MEANSRELATIVE TO BOTH OF SAID MEMBERS IN RESPONSE TO LONGITUDINAL MOTION OFONE OF SAID MEMBERS